Here’s the release from the Southeastern Colorado Water Conservancy District (Chris Woodka):
The James W. Broderick Hydropower Plant at Pueblo Dam was dedicated on Monday, September 16, , before a crowd of about 100 people.
The hydroelectric generating facility was completed in May 2019 and is named for James W. Broderick, executive director of the Southeastern Colorado Water Conservancy District.
Southeastern President Bill Long hailed Broderick’s vision for pursuing the project under a Lease of Power Privilege with the U.S. Bureau of Reclamation. The process was started in 2011, and culminated in 2017, when the lease was signed. Construction of the $20.5 million plant took 18 months.
“Jim has given a lot more than his name to the James W. Broderick Hydropower Plant. It has been Jim’s vision to create this project, and to use the revenues generated by the plant to enhance the benefits of the Fryingpan-Arkansas Project,” Long said. “this is an example of the type of creative thinking and leadership that Jim brings to every aspect of his service to the Southeastern District.”
Broderick, in accepting the honor, credited his wife Cindy and their daughter Amy for his own success as a water leader not only in southeastern Colorado, but throughout the state and the western region. Broderick currently is president of the Colorado River Water Users Association, and has led other agencies within the state, including Colorado Water Congress and the Arkansas Basin Roundtable.
Broderick also recognized the Southeastern District’s early partners in the Lease of Power Privilege, Colorado Springs Utilities and Pueblo Water, for technical assistance and support in bringing the power plant project to completion. Other contributors during the planning and construction process included Black Hills Energy and Pueblo West.
[Those on] hand for the event [included] Brenda Burman, Commissioner of Reclamation, and Becky Mitchell of the Colorado Water Conservation Board…
Burman said the plant is one of 14 built on existing dams so far under a Lease of Power Privilege, and shows how maximum benefits can be realized from existing federal projects. Reclamation operates the Fryingpan-Arkansas Project in cooperation with the Southeastern District. The Project provides supplemental water for cities and farms in the Arkansas River basin by importing water from the Colorado River basin.
The Colorado Water Conservation Board provided a $17.2 million loan to construct the hydroelectric plant. Mitchell hailed the plant, which uses water to produce energy, as the type of project the state will become involved with as it moves in the future.
The power plant will generate, on average, 28 million kilowatt hours of electricity annually, enough to power 2,500 homes a year. It was constructed under a design-build contract with Mountain States Hydro of Sunnyside, Wash.
Power will be sold to the City of Fountain, and to Fort Carson, through Colorado Springs Utilities.
From the Yale School of Forestry & Environmental Studies:
Nearly 75 percent of coal-fired power plants in the United States generate electricity that is more expensive than local wind and solar energy resources, according to a new report from Energy Innovation, a renewables analysis firm. Wind power, in particular, can at times provide electricity at half the cost of coal, the report found.
By 2025, enough wind and solar power will be generated at low enough prices in the U.S. that it could theoretically replace 86 percent of the U.S. coal fleet with lower-cost electricity, The Guardian reported.
“We’ve seen we are at the ‘coal crossover’ point in many parts of the country, but this is actually more widespread than previously thought,” Mike O’Boyle, the co-author of the report for Energy Innovation, told The Guardian. “There is a huge potential for wind and solar to replace coal, while saving people money.”
Using public financial filings and data from the U.S. Energy Information Agency, O’Boyle and his colleagues analyzed the cost of coal-fired power plants compared with wind and solar options within a 35-mile radius. The report found that North Carolina, Florida, Georgia, and Texas have the greatest amount of coal capacity currently at risk of being outcompeted by local wind and solar. By 2025, Indiana, Michigan, Ohio, and Wisconsin will be in a similar situation.
“Coal’s biggest threat is now economics, not regulations,” O’Boyle told CNN Business.
Coal currently makes up just 28 percent of total U.S. power generation, down from 48 percent in 2008. Renewables, meanwhile, now account for 17 percent of electricity generation, dominated by hydro and wind, with solar capacity quickly growing.
Here’s the release from the Southeastern Colorado Water Conservancy District (Chris Woodka):
A hydroelectric generation plant at Pueblo Dam was named for longtime executive director Jim Broderick of the district which is building the facility.
The Southeastern Colorado Water Conservancy District Board Thursday unanimously passed a resolution naming the plant the James W. Broderick Hydroelectric Power Facility at Pueblo Dam when it is completed.
“Jim always takes a proactive approach through strategic planning and forward thinking in addressing the many and complex challenges that confront the Southeastern District, seeking solutions that are fair and equitable, and that protect and conserve the water resources of Colorado and the Southeastern District,” Board President Bill Long in proposing the resolution.
Broderick has led the team constructing the hydro plant through the initial steps for obtaining a Lease of Power Privilege from the Bureau of Reclamation to the eventual construction.
After obtaining final Reclamation approval to construct the hydro plant in 2017, the District signed a design-build contract with Mountain States Hydro of Sunnyside, Wash. Construction began in September of 2017, and is now substantially completed. Testing of the equipment at the plant is underway, and should be completed in May, when flows on the Arkansas River will increase to optimal levels for power production.
The $20.3 million hydro plant will use the natural flows released from the North Outlet at Pueblo Dam to the Arkansas River without consumption of any water. The plant uses three turbines and two generators individually or in combination to produce up to 7.5 megawatts of electricity at flows ranging from 35 to 810 cubic feet per second.
Based on historic averages, the hydro plant will be able to generate an average of 28 million kilowatt-hours annually, or enough electricity to power 2,500 homes.
The plant was funded by loans from the Colorado Water Conservation Board and the District’s Enterprise Activity.
“This is an important step for the District,” Broderick said. “We envision this as a long-term revenue source for Enterprise programs, such as the Arkansas Valley Conduit. Equally important will be the new source of clean power we have created.”
Power from Pueblo Dam Hydro will be sold to the city of Fountain, and to Fort Carson, through a separate agreement with Colorado Springs Utilities for the first 10 years of generation. For the next 20 years, Fountain will purchase all of the power generated by the plant.
“We’re very excited,” said Curtis Mitchell, utilities director for Fountain, and vice-president of the Southeastern Board. “This provides us with a source of clean electric power, and it has the added benefit of saving money for our ratepayers.”
FromThe Grand Junction Daily Sentinel (Dennis Webb):
A deal announced Tuesday will help both endangered fish in the Colorado River and the aging Grand Valley Power Plant hydroelectric facility near Palisade.
The Colorado Water Trust has reached a five-year deal with the Grand Valley Waters Users Association and the Orchard Mesa Irrigation District, the operators of the facility. Under the deal, water the nonprofit Colorado Water Trust will secure from upstream sources may be delivered to the nearly century-old plant during critical times of year, helping provide adequate water levels for fish in an important 15-mile stretch of the river just downstream of the plant.
Andy Schultheiss, executive director of the Colorado Water Trust, said a major goal is to deliver more water to the fish in the spring to help counter a drop in river flows that results when irrigation diversions have begun but runoff from mountain snowpack is still minimal. He said that phenomenon has come to be known as the “April hole,” although it has actually begun to happen earlier in the year. Warming temperatures have accelerated the start of irrigation and runoff seasons in Colorado.
The agreement is designed to help humpback chub, Colorado pikeminnow and other native endangered fish in the river. It also will benefit the plant and its operators by enabling the plant to run at a higher capacity when it doesn’t get enough water from other sources, including its own water rights, to maximize power production.
That should mean more revenue for the plant’s operators. In addition, the Colorado Water Trust has committed to contribute $425,000 to a $5.4 million rehabilitation project at the plant, which is nearly a century old. A Walton Family Foundation grant is making that contribution possible.
Schultheiss said the trust benefits by getting the ability to deliver water from upstream to the fish, without the possibility of the water being diverted by other users before it gets there. He said what has frustrated conservationists trying to get more water to what’s known as the 15-Mile Reach is that it can’t be protected from other upstream users unless there’s a purpose for it.
“It just so happens this plant is just upstream of the 15 Mile Reach so it’s perfectly located,” he said.
He said the trust will likely contract for water from an upstream reservoir for the project.
The upgrade work at the plant also will help protect the plant’s senior water rights, which benefit the fish. Those rights let the plant pull water from the Colorado River headwaters to the 15-Mile Reach without that water being available to holders of more junior upstream water rights.
“Working in partnership with the Colorado Water Trust to rehabilitate the Grand Valley Power Plant and more effectively utilize the capacity in the system is a win-win proposition,” Max Schmidt of the Orchard Mesa Irrigation District said in a news release.
Mark Harris of the Grand Valley Water Users Association said in the release, “In times of increased pressure on water supplies throughout the state, projects like this that further the interests of multiple sectors are sorely needed.”
In the release, Tom Chart, director of the Upper Colorado River Endangered Fish Recovery Program, which is led by the U.S. Fish and Wildlife Service, applauded those involved for “crafting this one-of-a-kind agreement.”
Energy analysts used power demand data from the Midwest’s January deep freeze and wind and solar conditions to find the gaps in an all-renewable power grid.
In the depths of the deep freeze late last month, nearly every power plant in the Eastern and Central U.S. that could run was running.
Energy analysts saw a useful experiment in that week of extreme cold: What would have happened, they asked, if the power grid had relied exclusively on renewable energy—just how much battery power would have been required to keep the lights on?
Using energy production and power demand data, they showed how a 100 percent renewable energy grid, powered half by wind and half by solar, would have had significant stretches without enough wind or sun to fully power the system, meaning a large volume of energy storage would have been necessary to meet the high demand.
“You would need a lot more batteries in a lot more places,” said Wade Schauer, a research director for Wood Mackenzie Power & Renewables, who co-wrote the report.
How much is “a lot”?
Schauer’s analysis shows storage would need to go from about 11 gigawatts today to 277.9 gigawatts in the grid regions that include New England, New York, the Mid-Atlantic, the Midwest and parts of the South. That’s roughly double Wood Mackenzie’s current forecast for energy storage nationwide in 2040.
Energy storage is a key piece of the power puzzle as cities, states and supporters of the Green New Deal talk about a transition to 100 percent carbon-free energy sources within a few decades. The country would need to transform its grid in a way that could meet demand on the hottest and coldest days, a task that would involve a huge build-out of wind, solar and energy storage, plus interstate power lines.
The actual evolution of the electricity system is expected to happen in fits and starts, with fossil fuels gradually being retired and the pace of wind, solar and storage development tied to changing economic and technological factors. The Wood Mackenzie co-authors view their findings, part of a larger analysis of utility performance during the polar vortex event, as a way to show, in broad strokes, the ramifications of different options.
We’ll Need More Than Just Today’s Batteries
A grid that relies entirely on wind and solar needs to be ready for times when the wind isn’t blowing and the sun isn’t shining.
During the Jan. 27 – Feb. 2 polar vortex event, a 50 percent wind, 50 percent solar grid would have had gaps of up to 18 hours in which renewable sources were not producing enough electricity to meet the high demand, so storage systems would need to fill in.
The grid would have to be designed to best use wind and solar when they’re available, and to store the excess when those resources are providing more electricity than needed, a fundamental shift from the way most of the system is managed today.
“In a modern power grid, all these advanced technologies are driving the need for more flexibility at all levels,” said David Littell, principal at the Regulatory Assistance Project and a former staff member for Maine’s utility regulator. Grid operators have to meet constantly changing electricity demand with the matching amount of incoming power. While fossil fuel power plants can be ramped up or down as needed, solar and wind are less controllable sources, which is why energy storage is an essential part of planning for a grid that relies on solar and wind.
Much of the current growth in energy storage is in battery systems, helped by plunging battery prices. A large majority of the existing energy storage, however, is pumped hydroelectric, most of which was developed decades ago. Other types of systems include those that store compressed air, flywheels that store rotational energy and several varieties of thermal storage.
Schauer points out that advances in energy storage will need to be more than just batteries to meet demand and likely will include technologies that have not yet been developed.
And that won’t happen quickly. He views the transition to a mostly carbon-free grid as possible by 2040, with the right combination of policy changes and technological advances. He has a difficult time imagining how it could be done within the 2030 timeframe of the Green New Deal.
‘This Is a Solvable Problem’
The larger point is that such a transition can be done and is in line with what state and local governments and utilities are already moving toward.
Feasibility is a key focus of the research of Mark Jacobson, a Stanford University professor, who has looked at how renewable energy and storage can provide all of the energy the U.S. needs.
He says an aim of using all renewables by 2030 is “an admirable goal” but would be difficult to pull off politically. He thinks it’s more realistic to get to 80 percent renewables by 2030, and get to 100 percent soon after.
“This is a solvable problem,” Jacobson said, adding that it must be solved because of the urgent need to reduce emissions that cause climate change.
Local politics may be the most challenging part of quickly making an all-renewable electricity system, Schauer said. To handle a big increase in wind, solar and storage, communities would need to be willing to host those projects along with the transmission lines that would move the electricity.
Interstate power lines are essential for moving electricity from places with the best solar and wind resources to the population centers. As more solar and wind farms are built, more lines will be needed. Schauer’s analysis assumes that there would be enough transmission capacity.
“I’m not here to say any of this is impossible, but there are some basic challenges to pull this off in a short period of time, mainly NIMBYism,” he said, referring to the not-in-by-backyard sentiment that fuels opposition to transmission lines.
Another important element is managing electricity demand, which is not discussed in the Wood Mackenzie report. Littell says some of the most promising ways to operate a cleaner grid involve using technology to reduce demand during peak periods and getting businesses to power down during times when the electricity supply is tight. Energy efficiency improvements have a role, as well.
Nuclear Power Would Lower Storage Needs
In addition to the 50-50 wind-solar projection, Schauer and co-author Brett Blankenship considered what would happen with other mixes of wind and solar power, and if existing nuclear power plants were considered as part of the mix.
By considering the role of nuclear plants, the report touches on a contentious debate among environmental advocates, some of whom want to see all nuclear plants closed because of concerns about safety and waste, and some who say nuclear power is an essential part of moving toward a carbon-free grid.
The Wood Mackenzie analysis shows that continuing to use nuclear power plants would dramatically decrease the amount of wind, solar and storage needed to get to a grid that no longer burns fossil fuels. For example, 228.9 gigawatts of storage would be needed, compared to 277.9 without the nuclear plants.
“If your goal is decarbonization, then nuclear gets you a lot farther than if you retire the nuclear,” Schauer said.
While the report focuses on a few cold days this year, Schauer has also done this type of analysis based on data for all of 2018, including summer heat waves. The lessons are similar, underscoring the scope of the work ahead for the people working for a cleaner grid.
“It gets even more challenging when you extrapolate to the entire year,” he said.
Public Utilities Commission says it has authority to hear dispute
La Plata Electric Association and other electrical co-ops may gain insight about buying out of a contract with their wholesale electrical supplier after the Colorado Public Utilities Commission ruled this week it can oversee a dispute about the buyout fee.
LPEA is exploring a buyout from its contract with Tri-State Generation and Transmission, in part, because the wholesaler caps how much renewable power LPEA can purchase from outside sources at 5 percent as part of a contract that does not expire until 2050. Tri-State is a nonprofit of 43 member electric cooperatives, including LPEA and Delta-Montrose Electric Association.
DMEA is interested in buying out of its contract because Tri-State’s prices have been rising since 2005, and, at the same time, electricity costs in general have fallen, said Virginia Harman, DMEA’s chief operating officer.
DMEA is also interested in developing more local renewable energy than allowed under its contract with Tri-State, she said.
“We are not looking for a free exit; we are looking for fair exit,” she said.
DMEA brought a case to the Public Utilities Commission last year because it felt the fee Tri-State demanded to buy out of its contract is unreasonable.
DMEA is formally asking the PUC to establish an exit fee that is “just, reasonable and nondiscriminatory,” according to a news release.
Becky Mashburn, spokeswoman for DMEA, declined to name the amount Tri-State is asking for the co-op to leave its contract.
Colorado’s PUC ruled Thursday it has the authority to determine whether Tri-State is charging DMEA a just and reasonable price to buy out of its contract, said Terry Bote, spokesman for the Department of Regulatory Agencies. A hearing about the buyout charge will be held in June, he said.
Tri-State had filed a motion to dismiss the case brought by DMEA, arguing the dispute about the exit fee is a contractual dispute.
The PUC rejected Tri-State’s argument, ruling the commission has jurisdiction over the buyout charge dispute because it is a statutory issue, he said.